Apparatus, method, and system for identifying, locating, and accessing addresses of a piping system

ABSTRACT

A method, system, and associated apparatus are described for installing, inventorying, actuating, and/or accessing down-hole equipment in a wellbore. This comprises tagging a casing by inserting permanent components of material compositions within sections along the length of a casing. Inserted components and/or portions of an original section function as unique readable active and/or passive markers. The piping system is at least one pipe having a plurality of markers placed in radial sections strategically arranged with independently identical or different material compositions or embedded in a length of the wellbore casing. The sections function as markers forming a readable pattern readable by the reader(s). The reader is one of or a combination of any of the group consisting of a plug, a probe, a sensor, and/or a computer for reading markers. The reader travels in either a forward or backward direction.

PRIORITY

This application is a continuation of and claims priority under 35 USC120 of Ser. No. 14/668,128 filed Mar. 25, 2015, entitled “Apparatus,Method, and System for Identifying, Locating and Accessing Addresses ofa Piping System”, which is a nonprovisional conversion of and claimspriority under 35 USC 119 from Provisional Application No. 61/970,563entitled “Apparatus, Method, and System for Identifying, Locating, andAccessing Addresses of a Piping System”, filed Mar. 26, 2014, andProvisional Application No. 61/970,775 entitled “Location andStimulation Methods and Apparatuses Utilizing Downhole Tools”, alsofiled Mar. 26, 2014.

TECHNICAL FIELD

This invention relates to apparatus, methods, and systems used forlocating and accessing addresses in one or more pipes. Morespecifically, the invention is directed to the drilling and completionof wells, such as hydrocarbon producing oil and gas wells. Mostspecifically, the invention involves locating specific addresses withinthese wells before, during, or after operating the wells.

BACKGROUND

Hydrocarbon fluids such as oil and natural gas are obtained fromsubterranean geologic formations (i.e., “reservoirs”) by drilling wellsthat penetrate the hydrocarbon-bearing formations. Once a wellbore hasbeen drilled, the well must be “completed” before hydrocarbons can beproduced from the well. A well completion involves the design,selection, and installation of tubulars such as production tubing, drillpipes, landing nipples, gas lift mandrels, flow control devices,subsurface safety valves, packers, and collars with associated tools andequipment, such as perforation guns, that are located in the wellbore.The purpose of well completion is to convey, pump, and/or control theproduction or injection of fluids in the well. After the well has beencompleted, increased production of hydrocarbons in the form of oil andgas begins.

In many cases it is necessary to lower one piece of equipment into thewell so that it can be installed, activated, inventoried, accessed, orotherwise manipulated according to a particular location in the wellbore(e.g., installing a gas lift valve in a particular gas lift mandrel whenthere may be several gas lift mandrels at different depths in thewellbore). Often it is necessary to perform a desired action at adesired location (e.g., a perforating gun that uses shaped charges tocreate holes in a well casing at a particular depth in the well).

In the past, rather complex methods have been used to determine when agiven piece of downhole equipment is in the desired location in thewellbore. These methods are often imprecise, complex, and expensive.

There is a continued need for developing more intelligent and adaptablemethods of drilling and completing oil and gas wells and for producinghydrocarbon containing fluids therefrom.

SUMMARY OF THE INVENTION

The present disclosure describes an apparatus, method, and systemprimarily designed for installing, inventorying, actuating, and/oraccessing down-hole equipment in a wellbore. The method and apparatuscomprises providing, first, a permanent structure such as a casing,collar, or other primarily cylindrical device, with an outer diameterthat is smaller than the diameter of a borehole, to be inserted withinthe well bore. The present disclosure includes modifying the casing byusing selected unique material compositions of pre-specified dimensionsthat reside inside and/or on an outer surface along a designated lengthof the casing. In this way, one or more patterns or sequences ofpatterns are developed along the casing providing a readableidentification (ID) code. The identification (ID) code can be detected,received via transmission, and/or stored using appropriate devices.These patterns are created by strategically placing sections ofmaterials of identical or differing composition(s) along both radial andaxial sections (portions) of the casing. These selected materials can beconductive or non-conductive and collectively provide an ID code whenused in combination with a reader.

More specifically the method involves installing, inventorying,actuating, and/or accessing down-hole equipment in a wellborecomprising;

-   -   (i) marking a wellbore casing by inserting permanent components        of selected material compositions within sections along a length        of said casing within said wellbore, wherein said components        and/or portions of an original section of said casing together        function as unique readable active or passive markers,    -   (ii) reading said markers, and;    -   (iii) acting upon reading said markers using at least one        reader.

The reader associated with both the method and apparatus, that completesone aspect of the system, is the use of any device including a probe,plug, sensor, code scanner, bar code scanner and/or computer thatsearches, acquires, senses, analyzes, stores, manipulates, and/orredirects data acquired from the casing. In other words, the readerdevice must be capable of distinguishing changes in the strategicplacement of the different material compositional sections, and theassociated material properties that are placed in or on these sectionsalong the length of the casing, pipe, or piping system.

The method includes inserting markers in strategically placed locationsalong an axial and/or radial portion of the casing creating one or morepatterns or sequence of patterns wherein the markers are comprised ofcomponents each possessing, independently, identical or differentselected material compositions with corresponding cross sectional areas.The material compositions may be solid conductive or non-conductivemetals, wire and/or screening metals, and/or polymers that may or maynot be filled with conductive and/or magnetic fillers. In oneembodiment, these sections are often conductive or non-conductive radialrings, comprised of independently the same or different materials andchangeable dimensions along both the radial and axial direction of acollar. These rings also function as markers in that the insulative orconductive (or at least semi-conductive) alternating material propertiesalong the continuous length of the collar provide the ability for thereader to read specific addresses. The pipes and piping systems may beused for purposes other than oil and gas well completion. In oneconfiguration, at least two or more of the components are conductiverings which, when energized, comprise active markers, that together withpassive markers along the length of the casing, individually orcollectively function by providing a readable identification (ID) codecreated when one or more patterns or sequence of patterns are read bythe reader. The readable identification (ID) code obtained from thepatterns provides the ability to determine precise locations along aspecific length of the casing. These locations are specific addressesthat correspond with a detectable feature at the surface of, or embeddedin, the casing. By providing the readable ID code in this manner, themarkers can appear as multiple patterned readable bars to a reader thatis reading, (in some cases by scanning), the permanent markers(sectional components) of the casing. These bars can be read as distinctspatial codes, distinct binary codes, and/or arranged to be read as barcodes.

Reading by scanning or otherwise acquiring and detecting the spatial,binary, and/or bar code with at least one reader, enables finding theexact address along the length of the casing. The casing is often aproduction collar within a borehole.

For this method the casing can be a production collar, and the at leastone reader is at least one probe wherein the probe is an autonomous tool(functioning on its own and in some cases being preprogrammed). Thereader can also be one or more tethered probes wherein at least oneprobe functions alone or in any combination as a plug, sensor, computer,recorder, detector, scanner, and/or barcode scanner. The at least oneprobe detects material property differences within the permanentcomponents within the sections (or portions of the sections) along thelength of the casing. The materials of composition and/or said markerscan have discontinuities in material properties including electricallyconductive materials with non-conductive gaps.

In yet another embodiment, the reader(s), as alluded to above, aresubstantially autonomous tools such as a probe. The probe functionssingularly, collectively (there may be multiple probes) or in anycombination as a sensor, computer with or without storage memory,recorder, scanner, and/or barcode scanner. Reading by the probe(s)occurs via transmitting, computing, recording, receiving, storing,distinguishing and/or measuring, at least a portion of data received bythe probe or exchanged between multiple probes, as needed. Data signalscan be actively or passively transmitted from the casing. The probe canbe moving or stationary and the data signals are read while the probe ismoving or stationary. Likewise, the collar and/or casing may be movingor stationary. In this embodiment, the casing itself can be acting as aprobe and the casing could be moving or stationary. The probe could alsobe moving or stationary separately or in concert with the casing.Signals are read while the probe (or casing/collar) is moving orstationary.

In an additional embodiment, the at least one probe functions as asensor that senses changes in permanent components of selected materialcompositions along a length of the casing. This method is used whenpermanent marking of the casing is desired. Here again the casing couldbe a production collar installed in the wellbore. Permanent componentsare placed as radial sections in and along the length of the casing.Marking of the casing is accomplished before or during the casinginstallation, and/or marking is in production collars being installed inthe wellbore. The probe acting as a sensor provides readable (ID) codethat identifies specific collar features. More specifically, providingthe readable ID code to a reader is one method for identifying specificcollar mechanisms. Even more specifically, providing the readable IDcode to a reader is another method for identifying branching of aborehole collar. In all cases, the readable ID code is being read by thereader and the reader can be stationary or moving. The code can also beread while the reader is moving in either a forward or backwarddirection. To ensure the overall code can be read in both directions,the code is normally provided with both a leader code and a trailercode. This distinguishes not only precise addresses (locations), butalso the direction and location associated with the code.

Readable ID code to the probe (or any reader) assists in identifyingspecific borehole features. Providing the readable ID code to a readerassists in identifying specific casing mechanisms (such as valves).Providing the readable ID code can assist in identifying branching of aborehole casing. The readable ID code can be read by the reader when itis moving in either a forward or backward direction. The readable IDcode can be read by a reader, which is tubing conveyed, on a wireline,or independently propelled, so that the code is translated into data,wherein the data is sent to an uphole surface of a wellbore. Thereadable ID code can be conveyed uphole to the surface by sending datafrom the code obtained to the uphole surface.

It is also possible to provide readable ID code read by a reader whereinthe reader is not connected to the uphole surface. In this case, thereadable ID code is read by a reader connected to equipment not limitedto measuring, computing, recording and/or actuating. The readable IDcode is read by a reader moved by fluids in the wellbore and not limitedto fluids for pumping and production. In one of yet another set ofembodiments, the readable ID code is read by at least one reader movedby gravity, moved by buoyancy in the fluid, moved by self propulsion, orany combination of these methods, during use within the well. In analternative embodiment, the readable ID code is read by a reader movedby self propulsion.

For the methods described above, the reader (probe or other devices) hasthe ability to take action upon reading readable ID code. This actioncan include; releasing mechanical keys, actuating an electrical,magnetic, electromagnetic, pneumatic, hydraulic, fiber optic device orother communications circuit, and/or initiating measurements of thesedevices or circuits before, during, or after well completion. In manycases, these measurements are regarding the collar, borehole, as well assections and portions of sections along the length of the piping.

The action upon reading readable ID code can be communicating withequipment along a length of the casing. Actuating communications can beaccomplished autonomously by the probe, or remotely using communicationsto the equipment at the surface of the borehole.

An additional embodiment includes a piping system comprising; at leastone pipe having sections strategically arranged so that the sectionscomprise independently identical or different material compositionsalong a surface or embedded in, a length of said pipe, wherein aplurality of passive and active distinguishable markers are placed inthe sections forming a readable pattern or sequence of patterns that isread by at least one reader, thereby locating specific addresses alongthe length of the pipe.

In yet another embodiment, at least one device is comprised of a unitfor reading markers along a length of a piping system that readsstrategically arranged sections of at least one pipe where the sectionscomprise independently identical or different material compositionsalong a surface or embedded in, a length of the pipe, and whereinmarkers are placed on or in the sections so that the markers form areadable pattern or sequence of patterns that are read by the unitthereby providing data and specific addresses along the length of thepipe.

In another embodiment, at least one device is comprised of sections inat least one pipe strategically arranged so that the sections compriseindependently identical or different material compositions along aninner surface, an outer surface, or between inner and outer surfacealong a length of pipe, so that the sections themselves form adistinguishable readable pattern or sequence of patterns that are readby at least one reader.

In a further embodiment, at least one pipe comprises a plurality ofpassive and active markers placed in sections strategically arranged sothat sections comprise independently identical or different materialcompositions along a surface or embedded in, a length of pipe, so thatmarkers form a readable pattern or sequence of patterns readable by atleast one reader.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1A is a schematic drawing of a completed assembly of an untetheredprobe that is fully housed in a smooth enclosure.

FIG. 1B is a schematic depicting an untethered probe within a casingwith a top half of the probe having an outer surface covering and alower half having the outer surface removed so that the coiled sensorscan be viewed. The probe is depicted to be within a coded casing.

FIG. 1C is a cross-sectional schematic view of the internal portion ofan untethered probe with a rounded end. The probe is depicted to beinserted within a coded casing.

FIG. 1D is a schematic depicting the external surface of a tetheredprobe with a tapered end residing within a cross-section of a codedcasing.

FIG. 1E is a schematic of a cross-sectional internal portion of atethered probe with a tapered end, including bulkhead and electricalcomponents. The probe is depicted to be within a coded casing.

FIG. 2A illustrates a portion of a probe with a threaded male adapter.

FIG. 2B illustrates an untethered probe with a female jacketed upperend.

FIG. 2C illustrates a tethered probe with a female jacketed coveredupper end.

FIG. 3A is a schematic depiction of a cross-sectional portion of a codedcasing and a portion of a probe with a single coiled sensor.

FIG. 3B is a sample of data output from the probe using a single sensorfor sensing differences in a coded casing.

FIG. 4 is a visual display of the readable identification (ID) code of acoded casing and associated digital signals obtained during reading.

FIG. 5 is a schematic representation of an alternate embodimentdepicting a casing with sensors using a coded probe.

FIG. 6 is a schematic of multiple coded ringed sections and associatedcoded signals received by insertion of the ringed sections within acasing or a reader (probe).

FIG. 7A depicts the use of multiple sensors for reading multiple codedrings.

FIG. 7B depicts the output signals received when using a single movingsensor for reading multiple coded rings

DETAILED DESCRIPTION

As summarized above, one embodiment of the present invention is a methodof installing, inventorying, actuating, and/or accessing down-holeequipment in a wellbore comprising;

-   -   (i) marking a wellbore casing by inserting permanent components        of selected material compositions within sections along a length        of said casing within said wellbore, wherein said components        and/or portions of an original section of said casing together        function as unique readable active or passive markers,    -   (ii) reading said markers, and;    -   (iii) acting upon reading said markers using at least one        reader.

I. Providing a Coded Casing

In this embodiment, the method (and overall system) involves insertingmarkers in strategically placed sections of the pipe, so that patternsor sequences of patterns are created along and within an (axial and/orradial) portion of a pipe, piping system, collar, or casing. Markers arecomprised of (in most cases radial) sections each possessing,independently, identical or different selected material compositionsthat are either on the surface or embedded within cross sectionalsections of the casing. In one embodiment, the casing provides two ormore sections (or rings inserted into the casing) that are; conductiveand/or non-magnetic, non-conductive and/or magnetic, or non-conductiveand/or non-magnetic. Using these sections (rings) collectively along thelength of the casing creates the basis of a readable identification (ID)code. The code corresponds with one or more specific patterns due to theinsertion of different material compositions in the casing, which allowsfor distinguishing the markers. The different material compositions,exhibit contrasting resistivity values along the length of the casing.By inserting these different sections (and/or markers) into the casing(in some cases sections of the rings are composed of differentmaterials), a basis is formed for determining discrete locations thatare specific addresses based upon reading the ID code. The addresses areread and correspond to code that exists as portions of the casing. Thesecasing sections and associated portions are either conductive,non-conductive, semi-conductive, magnetic, non-magnetic, radioactive,non-radioactive, energized and/or non-energized, resulting in readablepatterns or sequences of patterns.

Collectively, the sections, with or without markers, are placed alongthe casing (or collar). Rings (acting as markers), with varyingthicknesses and widths, can be inserted directly into sections of thecasing and thereby provide readable pre-addressed ID code thatcorresponds to a precise address in the casing. In this manner, thepre-addressed ID code can be developed as either a type of passive oractive “casing code”. How the code is detected, received, and/ortransmitted is dependent on which materials are used for each section ofthe casing (or the types of rings used and their placement). The casingsections or the rings or both may be “doped” with additional elementsthat can be read (detected) by the reader. In this case “doping” isintended to mean adding specific features to the overall materialcompositions that can be activated or that can be easily detected.Detectable properties and associated property values and/or signals canbe emanated, transmitted, absorbed, and/or reflected and then read frommaterials requiring no doping (such as magnetic or conductive materials)as well as from doped materials.

It is possible to embed, by doping or other methods, specific materialsin the casing and/or markers. It is also possible to insert electrical,mechanical, magnetic, electromagnetic, and/or optical circuits orcorollary circuitry into these specific materials. The types of embeddedcircuits for example may include active or passive resonant circuits,transformers, analog or digital transponders. The detectable propertiesand/or signals can be detected by distinguishing some aspect of amaterial property including magnetic fields and resulting magneticeddies, from sensors, and/or from (frequently programmed) circuitry. Inall cases, the overall material composition of the rings and/or othersections of the casing are different and these detectable, readabledifferences, provide patterns or a sequence of patterns.

Sections (or portions of sections) of the casing which arenon-conductive and/or are void of circuitry will not emit or emanatesignals. Instead, these “passive” non-energized sections of the casingalso have detectable properties (e.g. resistivity, conductivity and/ormagnetism), which when used to provide a basis for distinguishable code,assist in locating other addresses. The addresses, based upon the casingproperties that are detected, are found when a specific length of thecasing (with or without markers) provides a fully developed code alongthat specific length. In this manner, the entire casing (or collar) canbe logged (mapped). This allows the casing to act as a “passive codeproviding” device. In order to read this code, at least one code reader,such as a probe, must be employed. The reader will also be selected tobe active or passive, depending on the properties of the casing.

It must be emphasized, that a key aspect of the present invention isthat the casing (or pipe or pipeline or collar) within the borehole, ispermanent. This allows for the creation of a robust and extremely longlived (in comparison with any other systems) wellbore address locatorthat functions during the entire life of the wellbore. As previouslystated, the readable identification (ID) code provides the reader oruser or both, with the ability to determine precise locations along alength of the casing. These locations are specific addresses thatcorrespond with a detectable feature at the surface of, or embedded in,the casing. By providing the readable ID code in a permanent manner, themarkers can appear as multiple patterned readable bars to a reader thatis reading, (in some cases by scanning), the permanent markers(sectional components) of the casing. Taken in total (collectively), thebar codes are permanent identification (ID) codes which when read by asingle probe (or multiple probes) are capable of providing positionaland overall compositional make-up of specific local addresses along thecasing. In this manner, the casing is fully “logged” and the wellbore iscompleted with a “signature” that allows acting with precision withinthe wellbore, where and when needed. In order to ensure meeting theserequirements additional embodiments of the present invention exist.

II. Providing an Active Reader for Reading the Coded Casing

In all cases described, the reader can be a probe, a scanner, a bar codescanner, a computer, a detector, a transmitter and/or a receiver thattravels inside the coded casing described above. In one instance, a datasignal is emitted by a reader—in this case a probe—and sent to thecasing for reading the code. The signal is subsequently “reflected” andreceived by the same or a different probe or set of probes, yielding atleast position and material composition dependent data obtained from thecoded casing.

In a special set of embodiments that is diagrammed schematically inFIGS. 1-4 described herewithin, the casing has to least one permanentidentification (ID) codes using materials which exhibit differentresponses to eddy current measurement. The probe measures the eddycurrent effect in the casing and the permanent identification (ID)codes.

The eddy current effect is well understood by those trained in the art,but is described more fully as follows: the probe emits energy which canbe detected and invokes a response from the coded casing. In this casethe probe emits electromagnetic radiation resulting in eddy currents inthe coded casing, which are measured by eddy current sensors, as theenergized probe travels along the length of the casing (or collar). Theprobe could also function as a receiver to receive signals from thecasing (described in more detail below). Different material compositionsin the coded casing exhibit different resistivity values. Copper, forinstance, is a good conductor of electricity but is non-magnetic andexhibits a low resistivity, in comparison with steel. Steel exhibits ahigher resistivity than copper but is magnetic. Plastics are neitherconductive nor magnetic unless filled or otherwise treated withconductive and/or magnetic elements.

In this embodiment, the resistivity differences due to the varyingmaterial compositional sections (which may be markers) along the lengthof the casing, are determined by non-contact eddy current measurementtechniques. As a result of sending a small amount of current (mA) intoan eddy current sensor, a magnetic field and associated eddy current isinduced. Most specifically, at least one ring shaped eddy current sensorand underlying eddy current ring shaped shield is placed either on thesurface or embedded within the probe. This combination masks the sensingof eddy currents inside the probe. This technique ensures that there isno interference in the measurement of either the magnetic field orresultant eddy current due to the presence of the probe. The shields areoptional, but preferred.

Without this shielding on the probe, the ability to perform the desiredmeasurements of eddy currents in the coded casing would be greatlydiminished. The eddy current shield underlying the eddy current sensorresults in directing the sensitivity of the sensor in a radial directionaway from the probe and therefore toward the casing. This techniqueensures that the sensor preferentially measures, almost exclusively,resistivity differences existing in the various material compositionalsections (or markers or both) along the length of the casing.

The probe associated with this system also functions as a reader of thecoded casing. The coded casing is read by sensing (as the probe istraveling in either direction and at times stationary within the casing)markers that correspond with the equivalent of bars having differingwidths formed by “seeing” portions of rings embedded along the length ofthe casing. These patterns collectively, when read, provide casingcodes. Collectively, these bars make-up the patterns that essentiallyare the same as a bar code. The probe, therefore, in this case, servesat least two functions; reading casing code and providing eddy currentsensor(s) that measure resistance of the different material compositionsin the casing. The measurements depend on the probe's location withrespect to specific sections (markers, rings, etc.) within and along thecoded casing.

By inserting into the casing at least one marker (ring) made withmaterials exhibiting a low resistivity but no magnetic permeability(i.e. copper or silver) and another marker (ring) with materialsexhibiting a high resistivity and high magnetic permeability (i.e.ferrite) it is possible to distinguish these markers (either in the formof rings or as sections of the casing itself) from one another, bycomparing eddy current values using the eddy current sensors carried bythe probe.

Another function of the markers (rings) is to shield the (metallic)casing from being measured by the eddy current sensor (thereby maskingthe casing). To ensure full shielding of the casing occurs, in the caseof the low resistivity but non-magnetic permeability ring (i.e. copperor silver), the material must be significantly thicker than the skineffect utilized by the eddy current sensor. In the case of the markers(rings) exhibiting a high resistivity and high magnetic permeability(i.e. ferrite), the induced magnetic field providing the eddy currentsensor never reaches the metallic casing.

Most specifically, in developing the probe and associated passive codegenerating device (i.e., the casing, etc.), it is important to generate“clean” signals. Here, the word “clean” refers to signals that aremostly free from or easily contrasted with background noise, are easilydetectable, are determined to be from an exact and specific source, areclearly resolved, and if necessary, amplified. These signals provide amethod for the probe to act or react as needed and in some cases, thesignals may be sent uphole for a user to interpret.

By utilizing both a probe and coded casing as described, anuninterrupted, unimpaired, easily detected material property change inthe markers (rings) is accomplished using easily detected changes ineddy current values received from the coded casing on a permanent basis.

Additionally, the probe may be moving or stationary and includes severalfeatures that allow for ease of travel within the fluid regions confinedwithin the casing (or collar) residing in the borehole. These featuresinclude geometry constraints such as pointed or rounded mechanicalportions of the probe at one or both ends. The probe must be water andpressure resistant and as “leak proof” as possible to withstand harshpressure and temperature downhole conditions during operation. Inaddition, the probe can also include some form of random access memory(RAM) included with a computing device (computer) and with electronicspowered by a power source, such as a battery.

The combination code-and-reader system is shown in FIGS. 1A-1E. FIG. 1Ais a schematic representation of one type of a code-and-reader system[100], with a casing [102] shown to contain a probe [110] having anouter portion (surface) [120], a conical terminus [128] with an optionalaccess point [129] for a connector (not shown) and an upper end probeportion [127]. The probe [110] depicted in FIG. 1A is an example of anuntethered probe [112] having a rounded upper end probe portion [127].The outer portion (surface) [120] is smooth and void of externalfeatures so that there is no interference with the motion of the probe[110] or in communicating with the probe [110] while in the casing[102].

FIG. 1B is also a code-and-reader system [100], with a casing [102] thathas different material sections functioning to provide a coded region(set of rings) within the casing [105] The casing houses a probe [110]having an outer probe portion (surface) [120], a conical terminus [128]with optional access [129] for a connector (not shown), an upper endprobe portion [127], sensor coil(s) [125] which extend along thecircumferential surface of the foil shielding [124] of the probe [110]and are connected via a wiring bundle for sensor coils [126]. The probe[110] depicted in FIG. 1B is an example of an untethered probe [112]having a rounded upper end probe portion [127], thus providing anautonomous probe capable of operating without further mechanicaldirection.

The coded region of the casing [105] is constructed from differentmaterial sections positioned along the casing [102] in such a manner asto provide “readable” variations in the casing [102] creating a codedcasing with an exact address. The sensor coil(s) [125], when energizedprovide sensing capability to interpret the code from the coded regionof the casing [105].

FIG. 1C is a cross-sectional area depicting the untethered probe [112]version of the code-and-reader system [100] of FIG. 1B. The innercross-sectional portion of the probe [150] provides the probe [110], inan untethered probe [112] version, with a pressure vessel [160]component and a female jacketed upper end [180] component (shown asrounded). The female jacketed upper end portion [180] of the probe [110]holds mechanical components which can operate at normal well borepressures.

The power supply unit [158] provides energy to the components of theprobe [110] via an electrical wiring system. Energy is distributed tothe electronic sensor and control board [156] in order to energize themotor and shaft [162] for the rotating of the magnetic couplings,provided as an inner portion of the rotating magnetic coupling [164] andthe outer portion of the rotating magnetic coupling [166]. Withreference to the inner and outer portion of the rotating magneticcouplings [164,166], “inner” refers to the portion of the rotatingmagnetic coupling that is inside the pressure vessel [160] and “outer”refers to the portion of the rotating magnetic coupling that is outsidethe pressure vessel [160]. The coupling can also be comprised ofpermanent magnets.

The magnetic coupling [164,166] operates using the motor and shaft [162]and provides a magnetic field [167], which couples the torque of themotor [162] through the magnetic coupling seal [168] to the outermagnetic coupling[166]. This coupling ensures that the seal of thepressure vessel [160] protects the internal elements within the pressurevessel [160].

The pressure bulkhead [152] is an electrical feed-through that serves asa junction for the wiring system and also energizes the probe [110]. Itis housed in the conical terminus [128] of the probe [110]. Wiring fromthe pressure bulkhead [152] extends to the outer probe portion (surface)[120] and along the circumferential surface of the foil shielding [124]of the probe [110], thereby creating the sensor coil(s) [125]. Anaccelerometer [153] is shown and can be wired to the pressure bulkhead[152]. The accelerometer [153] is essential for a single sensor coilprobe (as shown in FIG. 3A) so that the measurement of velocity of theprobe can be obtained.

FIG. 1D is a code-and-reader system [100], with a casing [102] usingdifferent material sections, provides a coded region of the casing[105], housing a probe [110] having an outer probe portion (surface)[120], a conical terminus [128] with optional access [129] for aconnector, an upper end probe portion [127], and sensor coil(s) [125]which extend along the circumferential surface over the foil shielding[124] of the probe [110]. The sensor coils [125] are connected via awiring bundle for the sensor coil(s) [126]. The probe depicted in FIG.1D is an example of a tethered probe [114] having a tapered upper endprobe portion [130] and an uphole tether [176] capable of communicationand mechanical attachment with the probe.

FIG. 1E is a cross-sectional illustration of the tethered probe [114]version of the code-and-reader system [100] of FIG. 1D. The innercross-sectional portion of the probe [150] provides a pressure vessel[160] component and a female jacketed upper end portion [180] component(shown as a tapered section). The casing of the pressure vessel [160]component is threaded (or otherwise attached) together with the femalejacketed upper end portion [180] of the probe [110] to maintain a sealedsystem at atmospheric pressure (P_(ATM)).

The power supply unit [158] provides energy to the components of theprobe [110] via an electrical wiring system. An alternative embodimentof the invention is that energy is provided via an uphole power supplyto the downhole components of the probe [110] via an electrical wiringsystem through an electrical connector [174] to an uphole tether [176].Energy is distributed to the electronic sensor and control board [156]in order to energize the motor and shaft [162] for rotating of themagnetic couplings. These couplings are shown as an inner portion of therotating magnetic coupling [164] and an outer portion of the rotatingmagnetic coupling [166].

Rotation of the magnetic couplings [164,166] by the motor and shaft[162] creates an induced magnetic field [167] (also able to be providedthrough the use of an alternative permanent magnet arrangement) whichensures sealing, with the optional seal cup [168] the pressure vessel[160] component and the female jacketed upper end portion [180] tomaintain safe operation of the internal elements of the pressure vessel[160].

The pressure bulkhead [152] is an optional electrical feed-through thatserves as a junction for the wiring system that energizes the probe[110], and is housed in the conical terminus [128] of the probe [110].Wiring from the pressure bulkhead [152] follows to the outer probeportion (surface) [120] extending along the circumferential surface ofthe foil shielding [124] of the probe [110] and creates the sensorcoil(s) [125]. An accelerometer [153], is shown as wired to the pressurebulkhead [152], and is an optional component for a dual sensor coilprobe as shown but required as sated above for a single sensor coilprobe,

FIG. 2A is an outer surface schematic of the pressure vessel [160]component of the probe [110] (not fully featured), with the taperedthreaded male adaptor portion [240]. Eddy currents [230] generated byenergizing the sensor coil(s) [125] allows for receiving a response fromthe coded region of the casing [105] are shown.

FIG. 2B is an outer surface schematic of the pressure vessel [160]component of the probe [110] (not fully featured), with the taperedthreaded male adaptor portion [240] completed by being connected with afemale jacketed upper end portion [180] component-shown as untetheredand rounded. Eddy currents [230] are shown which are generated byenergizing the sensor coil(s) [125] and allows for receiving a responseto the coded region of the casing [105].

FIG. 2C is an outer surface schematic of the pressure vessel [160]component of the probe [110] (not fully featured), having a taperedthreaded male adaptor portion [240] completed by being connected with afemale jacketed upper end portion [180] component—shown as tethered andtapered. Eddy currents [230] generated by energizing the sensor coil(s)[125] allows for receiving a response to the coded region of the casing[105].

FIG. 3A is a cross-sectional portion of the casing [102] exhibiting acoded region of the casing [105], where forward or backward, uphole ordownhole movement of the probe [110] allows for the sensing directionand specific addresses by the sensor coil(s) [125]. The sensors sensethe coded region of the casing [105]. An accelerometer [153] is added tothe probe here as a single coiled sensor and is capable of measuring thecode width if it travels at a generally constant speed. In this case,time is a factor in calculating the bar width which are determined bythe probe reading variable lengths of the coded casing. By adding anaccelerometer [153], changes in speed can be determined (if accelerationis known, speed can be calculated). By knowing the change inacceleration, the actual speed of the probe can be judged and therebygreatly diminish the effect of changes that the speed of the probe hason the quality of the readings of the ID code. As acceleration reacheszero and reverses, the accelerometer [153] is inadequate for reading thecode using a probe that moves in the forward and backward direction.Regions of the code are read using eddy currents [230], which are theresult of electrical current induced within the conductors of the coil,resulting in sensing changes in the magnetic field near the probe [110].The probe also optionally includes one or more of the followingcomponents in any combination; velocity change compensators,temperature, pressure, radioactive, optical, magnetic, electric, andelectromagnetic sensors. These sensors are provided for detecting,measuring, and distinguishing precise changes in position, materialcompositions, geological formations, speed, and acceleration within thefluid flowing in the casing.

In another embodiment, a single coil (as shown in FIG. 3A) resides in oron a probe which in this case is a sensor that moves at a known velocityto detect the width of the “ID bars” along the length of the casing.This probe is equipped with a “bar sensor”, which is typically acylindrical-shaped coil that is wrapped around the probe. The coil canbe conductive, provide a magnetic field, or both, and can be made from asolid or metal (or other at least semi-conductive material) mesh screen.The materials selection of this portion of the probe is designed to bematched with certain sections of the casing. This design is necessary sothat reading the code (provided by the changes of the materialcompositions in sections of the casing) is simple and occurs withlimited or no interference.

The plot in FIG. 3B indicates the amplitude of signals from the sensoras a function of time. The solid line shows the transition from Marker 2(M2) that indicates a difference in material composition between Marker1 (M1) and/or Marker 3 (M3). Each Marker will yield the same ordifferent responses in comparison to other Markers. The slope of thesolid line is proportional to the length of the Marker as it is read andsensed by the sensor. The slope shows the transition has some slopebecause of the width of the sensor. This is known as the apertureeffect.

Clean detection of the code establishes precise resolute addresses alongthe casing at any point in time. Using the code received directly fromthe casing, separately or together with measuring the parametersdescribed, allows for acting at specified addresses along the length ofthe casing with knowledge about this location before during or after anyaction is taken.

FIG. 4 is a visual example of how to determine the details of a codedregion of the casing [105]. The coded region of the casing [105] isconstructed of different material sections positioned along the casing[102] to provide “readable” variations in the casing [102] creating acode for an address. Variations in the coded region of the casing [105]are provided as short (S) and long (L) sections of compositionaldifferences where a long (L) section of the coded region of the casing[105] is a length detected by the probe which is at least two (2) timesthat of the short (S) section of the coded region of the casing [105].The length detected by the probe, L, of the short (S) section isgenerally about two (2) inches, thereby having a long (L) section of alength detected by the probe, 2L. Typically, the distance from thecenter of one sensor coil [125] to the center of the second (andsubsequent) sensor coil(s) [125] is a distance of 1.5 times the lengthdetected by the probe of the short (S) section of the coded region ofthe casing [105], or 1.5(L). The sensor coil(s) [125], when energizedprovide sensing capability to interpret the code from the coded regionof the casing [105]. Engineering markings of the figure, for explanativeand embodiment purposes, indicate preselected differences in thematerial composition of the casing (rings) in this section to be of thefollowing order;

(i) non-conductive plastic,

(ii) synthetic resin

(iii) magnetic

(iv) synthetic resin

(v) non-conductive plastic

(vi) synthetic resin

(vii) conductive material (metal)

(viii) synthetic resin

and finally a further type of non-conductive material.

Shorter and longer lengths of different material compositions correspondto patterns that collectively provide a code. These shorter and longerlengths are “read” by the probe inside the casing and correspond to theactual widths of the rings. Shorter or longer lengths “read” by theprobe can be either conductive, non-conductive, magnetic, non-magneticor insulative.

Conductive and/or magnetic sections are differentiated by the probe.Normally the longer lengths provide longer duration signals than theshorter lengths. By predetermining the lengths of sections of the ringsinside the casing it is possible to tailor signal durations. Forinstance, if the long lengths are twice the dimension of the shortlengths, the signal duration will be twice that of the short length.

Non-conductive and non-magnetic lengths (corresponding to widths of therings) are indicated in FIG. 4 as white coded regions, W. Black codedregions, B, correspond to conductive and magnetic, conductive andnon-magnetic, or magnetic and non-conductive material compositions.These are shown here to be Short White (SW) [402], Long Black (LB)[404], Short Black (SB) [406], and Long White (LW) [408]. Here, whiteregions correspond to readings of zero (0) and black regions correspondto readings of one (1). The short and long white coded regions differ inthe duration of the absence of a reading. Conversely, the short blackand long black coded regions differ in the duration of the presence of areading.

This system and corresponding techniques provides accurate, reliable,continuous, reading of the code by the probe. As previously stated, thevarious material properties are a permanent feature of the casing,thereby requiring no maintenance.

III. Providing an Active Casing for a Coded Reader

In another embodiment, as a corollary to the probe, the casing can emit,receive, measure and/or distinguish a signal or a property residing inor sent from within the material composition(s) of the casing. Thedetectable properties and/or emanating signals from the sections of thecasing are detected by using at least one reader, which, as describedabove, in one embodiment of the present invention, is a probe. In thisaspect of the invention, the casing itself can provide an “active” IDcode. The signals generated within the doped or circuitized materialcomposition of the casing can be adjusted (via amplification orotherwise), as required, so that the probe can read specific intendedlengths of the casing and provide exact addresses. By energizing thecasing, an inactive reader which is coded in the same or similar manneras described for the coded casing above is also possible. In this case,the probe receives data so that pinpoint accuracy of specific probeaddresses corresponding with the energized casing, is possible. Here,the casing provides two or more components that could be conductive andenergized active markers. As indicated, here a probe must be providedthat can accept data from imbedded sensors or circuits residing withinthe casing. The probe is coded and interprets the data from the casing.This allows for determining probe location and associated measurableparameters in that location. As before, the probe can be moving orstationary and can make measurements in a static or dynamic manner. Thesensors/circuits within the casing may be imbedded in an outer or innersurface or most likely recessed below the surface, to increase thelongevity of the use of any sensor/circuit in the downhole environment.The probe may also carry circuits or other devices that communicateeffectively with those embedded in the casing.

FIG. 5 is an inverse embodiment of the code- and reader system [100]shown in FIGS. 1A-1E. Here, the system is depicted as being providedwith a coded probe [500] and a casing [102] that contains sensor coil(s)[125] which are extended along the circumferential inner portion(surface) [502] of the casing [102] thereby turning the casing [102]into a “reader”. The probe [110] is provided with a coded region (set ofrings) of the probe [504]. The coded region of the probe [504] isprovided with the same type of predetermined lengths and coding key asdescribed for FIG. 4 above, specifically coding as before using ShortWhite (SW) [402], Long Black (LB) [404], Short Black (SB) [406], andLong White (LW) [408]

IV. Providing an Active Coded Casing and One or More Active CodedReaders

In a fourth instance, a signal from one or more active coded probes(readers) can be used to actuate some portion of the doped orcircuitized material composition residing within the casing. Actuationcan also be provided by an active coded casing that has embeddedenergized circuits or materials which emit detectable signals (or both).In this embodiment, the coded probe can act as a transmitter/receiver,the coded casing can act as a transmitter/receiver or it is possiblethat both the coded probe and the coded casing are active andcontinuously communicating with each other. In this instance, this wouldprovide additional data (from other codes or data sources) from specificlocations along the casing and/or trigger additional actions. Theseactions can be directed toward or within the casing as well as toward orwithin the probe. In other words, the probe as well as the casing mustbe capable of distinguishing changes in strategically placed materialproperties in or on sections along the length of the casing or theprobe. In addition, it is possible to actuate communication connectionsbetween a probe and another probe or between sections of the casing.

V. Ringed Sections with Different Material Compositions

As a corollary to (IV) above, it is also possible to provide ringedsections of the casing with rings having more than a single materialcomposition. In this embodiment, the use of one or more (n) sensorsallows for gathering more complete and precise data from these specially“doped” rings. FIGS. 6, 7A, and 7B graphically depict some of thepossible arrangements of such rings and the consequential codesequencing that can occur using the split ring arrangements shown.

FIG. 6 depicts a “dual track sensor array”. It illustrates across-section of a ring with the possibility of obtaining more than asingle code sequence from a single ring by identifying materialdifferences in the ring. Marks 1-5 are formed by using one method thatallows for the code sequence to be digitized. In this case, the numberof marks corresponds to the number of different detectable compositionsmaking up the ring. Each mark is read from a different material sectionof the ring and represents a different “track”. Each track is formedfrom sensing by a sensor (probe) that reads the track array. It is nowpossible to interpret a binary coded “0” and “1” system corresponding tosections of the ring being read by the probe in a continuous manner forsynchronizing the data regarding material changes inside the ring asseen by the probe. For readers, this also allows for obtaining dual barcodes to distinguish certain features of the pipe, casing, etc. In FIG.6, the Marks 1, 2, 3, 4 and 5 correspond to markers that providereadings (interpreted as a code) from a probe based on the position ofthe probe with respect to the material composition of the portion orregion of the ring being read by the probe. For the sections depicted inFIG. 6, a probe reads regions within the rings that are conductive,non-conductive, magnetic, non-magnetic, etc. thus providing thedifferent Marks that collectively comprise a code. To be able to readand interpret slight material compositional differences in each separatering along a pipeline by doping certain sections of the ring is veryuseful.

FIG. 7A is a schematic drawing that represents the ability of one ormore probes having at least N≥3 sensors reading the different (material)sections of the ring. The probe in this case is receiving (at least)data sets from the ring, rather than just single point data from ahomogeneous ring. FIG. 7B depicts the use of a single sensor on a singleprobe which will rotate at some predetermined rate. Here the number ofsensors (N) is N≥1 to ensure that the entire inner circumference of thering is properly read. FIG. 7A is intended to illustrate (by the arrowsdesignated as 701,702,703, and 704) sensors which can read multiplematerial sections of the ring, where N≥3 (as stated above). FIG. 7B is aschematic indicating a rotating sensor [710] that in this case is asingle sensor [720] which, depending on the speed of rotation may becapable of providing as much or more information to be interpreted ascode for the coded casing as that of the configuration shown in FIG. 7A.

One can envision that the system depicted in FIGS. 6 and 7A and 7B canbecome quite elaborate. To be able to read and interpret slight materialcompositional differences in each separate ring along a pipeline bydoping certain sections of the ring is very useful. This can only beaccomplished by and also providing a reader (probe) with enough sensors(or control of the sensors) to make multiple readings along the innercircumference of each of the “special” rings. The rings can be split inhalf, thirds, fourths, etc., and the readings will be based on thesensitivity of the probes used to read these differences. In any case,this method provides for being able to precisely know the exact addressof the ringed section that the probe is sensing.

VI. General Use of the Systems, Methods, and Apparatuses

The operation of this system, method and associated apparatusesdescribed, is dependent on the required usage. If for example, thedetermined ID code matches a target identification code, then one ormore downhole structures can be actuated, managed, classified,identified, controlled, maintained, actuated, activated, deactivated,located, communicated with, reset, or installed. For example, a seconddownhole structure can be installed inside a first downhole structure orone can unlock the other, etc.

The present invention also relates to the apparatuses that can be usedin the above described method as an overall system. For example, anotheraspect of the invention is a method of inventorying downhole equipment,and storing and retrieving identification codes for the inventoriedequipment, as well as an inventory of services performed on the well.This method allows an operator to create a database of theidentification codes of the pieces of equipment in the well and thelocation and/or orientation of each piece of equipment, and/or theequipment in which it is installed, and/or the services performed on thewell. With such a database, an operator could determine (either before,during, or after well completion) the equipment profile of a well andplan out the downhole tasks.

One embodiment of this method comprises a reader unit that receives thesignals transmitted by the identification transmitter units, decodes thesignals to determine the identification codes corresponding thereto, andstores the identification codes in memory. This method can furthercomprise the step of creating a database for the well, the databasecomprising the stored identification codes. The method can also comprisereading from the database the identification codes for the well (e.g.,the codes for equipment located in the well and/or the codes forservices performed on the well). The identification codes read from thedatabase can be used to perform at least one operation selected from thegroup consisting of managing, classifying, controlling, maintaining,actuating, activating, deactivating, locating, and communicating with atleast one downhole structure in the well

The system of the present invention has several benefits over prior artapparatus and methods. It provides a way of selectively installing,actuating, or inventorying downhole equipment at a desired time and/orat a desired location that is optionally independent of velocity of theprobe (reader) or location of sensors. In addition, the coding ispermanent in the manner described and is also essentially apertureinsensitive in comparison with, for example RFID sensor systems. Thissystem thereby provides lower cost, greater flexibility, betterlongevity and durability than other known existing techniques.

Another benefit of the present invention lies in the reduction ofdownhole tool manipulation time. In some cases, considerable downholemanipulation is performed to ensure that a tool is at the right point onthe downhole jewelry or that the right action is performed. This timeand effort can be eliminated or at least reduced by the presentinvention's ability to actuate or manipulate only when an exact (coded,i.e. bar coded) address has been reached or located so that an actioncan occur.

The present invention also makes use of non-acoustic transmission, suchas radio frequency transmission, optical transmission, tactiletransmission, magnetic transmission, and material conductivitydifferences for providing at least one identification code to locate,install, actuate, and/or manage downhole equipment in a subterraneanwellbore.

Another embodiment of the invention makes use of a detachable,autonomous tool that can be released from the end of a supportingstructure (e.g., coiled tubing, wireline, or completion hardware) whiledownhole or uphole, to then do some desired operation in another part ofthe well (e.g., spaced horizontally and/or or vertically from the pointat which the tool separates from the supporting structure). The tool canlater seek the end of the supporting structure, for example to enable itto be reattached, by homing in on the signal response from a transmitterunit embedded in the end of the supporting structure. Also, the tool canact as a repeater, actuator, or information relay device.

This relay of signal commands or information between autonomous agentsoptimized for submersible operations in different density fluids can usemultiple autonomous agents and perform across multiple fluid interfaces.This relay of signal commands or information between autonomous agentscan extend up or down-hole, between horizontal and vertical wellbores,and between multilateral wellbores and the main wellbore.

Another embodiment of the present invention uses the non-acoustictransmitter units to relay information from a downhole tool to a surfaceoperator. In this embodiment, the downhole tool has monitors and recordsdata such as temperature, pressure, time, or depth, for example. Thetool can also record data describing the position or orientation of apiece of equipment, such as whether a sliding sleeve is open or closed.Further, the tool can record data such as whether downhole tools andequipment have been installed or actuated. The non-acoustic transmitterunits can be dedicated to relaying a certain type of information or canbe used to relay multiple data types. This enables the correlation ofdata such as the temperature and pressure at the time of detonation.

Once the desired information is acquired by the tool, a microprocessoron the tool determines what information should be sent to the surface.The pertinent information is then written to a read/write non-acoustictransmitter unit that is stored in the tool. The transmitter units canbe stored in the tool in a variety of ways. For instance, thetransmitter units can be installed into a spring-loaded column, muchlike the ammunition clip in a handgun.

Alternatively, the transmitter units can be stored around the perimeterof a revolving chamber. The manner in which the transmitter units arestored in the tool is not important, as long as the required numbers oftags are available for use and can be released to the surface.

After the pertinent information is written to a transmitter unit, thetransmitter unit is released from the tool. It should be noted that thetransmitter unit can be released either inside or outside of the tooldepending upon the tool and the method of deployment. In one embodiment,when the transmitter unit is released, it is picked up by circulatingfluid and carried to the surface. The transmitter unit is interrogatedby a data acquisition device at the surface, at which time theinformation stored on the transmitter unit is downloaded. Themicroprocessor on the tool repeats the process with the additionaltransmitter units as directed by its programming.

In addition to tool-to-surface telemetry, as just described above, thenon-acoustic transmitter units of the present invention can be used tosend information from an operator at the surface to a tool located inthe well. In this case, the transmitter unit is written to and releasedfrom the surface, circulated to the tool below, and returned to thesurface. Once acquired by the tool, the information stored on thetransmitter unit is downloaded for use by the microprocessor.

Depending on the programming of the tool microprocessor, a wide varietyof instructions can be relayed from surface and carried out by the tool.Examples of possible instructions include how much to open a valve andwhether or not to enter a multi-lateral, for example.

In another embodiment, the non-acoustic transmitter units of the presentinvention can be used autonomously without the necessity of a downholetool. For example, the pumping fluid can be used to carry thetransmitter units downhole and back to the surface through circulation.The individual transmitter units can receive and store data fromtransmitter units located downhole in tools, pipe casing, downholeequipment, etc. Once returned to the surface, the transmitter units canbe analyzed to determine various operating conditions downhole. Such useprovides continuous monitoring of wellbore conditions.

In another embodiment, the non-acoustic transmitter units of the presentinvention are used to autonomously actuate or install downhole tools andequipment. In this embodiment, non-acoustic transmitter units aredropped down the wellbore affixed to a drop ball, for example. As thenon-acoustic transmitter units fall into proximity of non-acousticreceiver units located on the downhole tools and equipment, if thetransmitted signal matches a predetermined identification code, thedownhole tools and equipment are installed or actuated. It should beunderstood that both receiver units and transmitter units can be used toadvantage being dropped down the wellbore. For example, a receiver unitaffixed to a drop ball can carry information gathered from passing atransmitter unit affixed to the wellbore, tools, equipment, etc. andrelay that information to a receiver unit located further downhole.

In yet another embodiment of the present invention, the non-acoustictransmitter units can be placed along the wellbore and correlated withformation or well parameters or completion characteristics at thoselocations. When the well is logged; a digital signature for the wellborecan be created to pinpoint depth in the wellbore.

In summary, the present invention provides apparatus and methods formanaging, classifying, identifying, controlling, maintaining, actuating,activating, deactivating, locating, and communicating with downholetools, jewelry, nipples, valves, gas-lift mandrels, packers, slips,sleeves and guns. The invention allows downhole tools to actuate only atthe correct time and location and/or in the correct manner.

Although the present invention could be highly useful in any context,its benefits could be enhanced by a central organization that issuesnon-acoustic frequency identification units (encoding equipment serialnumbers) to manufacturers of downhole components. This organizationcould also maintain a database of downhole tool identificationcodes/serial numbers of all components manufactured. Such a list ofserial numbers could be classified or partitioned to allow for easyidentification of the type and rating of any particular downholecomponent. Non-acoustic frequency transmitter units can store andtransmit a signal corresponding to very large serial number strings thatare capable of accommodating all necessary classes and ratings ofequipment. Another suitable use of the invention includes packer landingverification.

The preceding description of specific embodiments of the presentinvention is not intended to be a complete list of every possibleembodiment of the invention. Persons skilled in this field willrecognize that modifications can be made to the specific embodimentsdescribed here that would be within the scope of the present invention.

We claim:
 1. A method of installing, inventorying, actuating, and/oraccessing down-hole equipment in a wellbore comprising; (i) marking awellbore casing by inserting permanent components of selected materialcompositions within sections along a length of said casing within saidwellbore, wherein said components and/or portions of an original sectionof said casing together function as unique readable active or passivemarkers, (ii) reading said markers, and; (iii) acting upon reading saidmarkers using at least one reader and wherein said at least one readeris at least one probe and wherein said probe is an autonomous tool andwherein said at least one probe directs magnetic fields in a radialdirection thereby measuring eddy currents and/or changes in eddy currentintensity, and wherein said probe is shielded and optionally whereinsaid at least one probe is unshielded.
 2. The method of claim 1, whereininserting said markers in strategically placed locations along an axialand/or radial portion of said casing is creating one or more patterns orsequence of patterns and wherein said markers are comprised ofcomponents each possessing, independently, identical or differentselected material compositions with cross sectional areas correspondingto each of said components.
 3. The method of claim 2, wherein at leasttwo or more of said components are rings made from different materialswith distinct measurable property differences along said length of saidcasing, wherein said rings collectively function by providing a readableidentification (ID) code created when said one or more patterns orsequence of patterns are read.
 4. The method of claim 3, wherein saidcomponents are materials with properties selected from one or more or inany combination from a group consisting of electrically conductive,electrically resistive, electrically insulative, electricallycapacitive, electrically inductive, magnetically permeable, magneticallynon-permeable, magnetically polarized, sonically transmissive, sonicallyabsorptive, optically reflective, optically absorptive, radiationabsorptive, radiation emissive that exhibit one or more features of saidmaterials and wherein said components can be rings comprising saidmaterials.
 5. The method of claim 3, wherein said readable ID code isread in precise locations along a length of said casing.
 6. The methodof claim 5, wherein said locations are a specific address correspondingto a feature either at the surface of, or embedded in, said casing. 7.The method of claim 1, wherein said markers appear as multiple readablebars to a reader that is reading said permanent components of saidcasing.
 8. The method of claim 7, wherein said multiple readable barscomprise a spatial, binary, and/or bar code.
 9. The method of claim 8,wherein reading by scanning said code with a reader provides an abilityfor finding a specific address along said casing and allows for carryingout an action at said address.
 10. The method of claim 1, wherein saidcasing is a production collar within a borehole.
 11. The method of claim10, wherein said at least one probe is singularly, collectively, or inany combination, reading, transmitting, computing, recording, receiving,distinguishing, and/or measuring, at least a portion of one or moresignals generated, emitted, and/or transmitted from said probe.
 12. Themethod of claim 11, wherein said signals are being actively generated,emitted, and/or transmitted from said casing.
 13. The method of claim11, wherein said signals are passively generated, emitted, and/ortransmitted from said casing.
 14. The method of claim 13, whereinutilizing said probe and coded casing results in uninterrupted,unimpaired, detected material property change in said markers by usingdetectable changes in eddy current values received from said codedcasing on a permanent basis.
 15. The method of claim 10, wherein saidcollar is moving or stationary.
 16. The method of claim 1, wherein saidreader is one or more tethered probes.
 17. The method of claim 1,wherein said at least one probe functions alone or in any combination asa plug, sensor, computer, recorder, detector, scanner, and/or barcodescanner.
 18. The method of claim 17, wherein said at least one probedetects material property differences within said permanent componentswithin said sections along said length of said casing.
 19. The method ofclaim 1, wherein said probe is moving or stationary and wherein saidsignals are read while said probe is moving or stationary.
 20. Themethod of claim 19, wherein said permanent components are placed asradial sections in and along said length of said casing.
 21. The methodof claim 1, wherein said at least one probe functions as a sensor thatsenses changes in said permanent components of selected materialcompositions along said length of said casing.
 22. The method of claim1, wherein said marking is accomplished while said casing is aproduction collar being installed in said wellbore.
 23. The method ofclaim 3, wherein providing said readable ID code to a reader assists inidentifying specific borehole features.
 24. The method of claim 3,wherein providing said readable ID code to a reader assists inidentifying specific features within a wellbore casing.
 25. The methodof claim 3, wherein providing said readable ID code assists inidentifying branching of a borehole casing.
 26. The method of claim 3,wherein said readable ID code is being read by said reader when saidreader is moving in either a forward or backward direction.
 27. A methodof installing, inventorying, actuating, and/or accessing down-holeequipment in a wellbore comprising; (i) marking a wellbore casing byinserting permanent components of selected material compositions withinsections along a length of said casing within said wellbore, whereinsaid components and/or portions of an original section of said casingtogether function as unique readable active or passive markers, (ii)reading said markers, and; (iii) acting upon reading said markers usingat least one reader and wherein said at least one reader is at least oneprobe and wherein said probe is an autonomous tool and wherein said atleast one probe directs magnetic fields in a radial direction therebymeasuring eddy currents and/or changes in eddy current intensity, andwherein said probe is shielded and optionally wherein said at least oneprobe is unshielded and wherein inserting said markers in strategicallyplaced locations along an axial and/or radial portion of said casing iscreating one or more patterns or sequence of patterns and wherein saidmarkers are comprised of components each possessing, independently,identical or different selected material compositions with crosssectional areas corresponding to each of said components and wherein atleast two or more of said components are rings made from differentmaterials with distinct measurable property differences along saidlength of said casing, wherein said rings collectively function byproviding a readable identification (ID) code created when said one ormore patterns or sequence of patterns are read and wherein said readableID code is read by a reader on a wireline so that said code istranslated into data, wherein said data is sent to an uphole surface ofa wellbore.
 28. The method of claim 27, wherein said readable ID code isread by a reader on a wireline which is conveyed by jointed piping, orcontinuous tubing, to said uphole surface.
 29. The method of claim 27,wherein said readable ID code is read by a reader on a wireline which isconveyed by a tractor or pipe crawler.
 30. The method of claim 27,wherein said readable ID code is read by a reader connected to equipmentnot limited to measuring, computing, recording and/or actuating.
 31. Themethod of claim 27, wherein said readable ID code is read by a readermoved by fluids in said wellbore and not limited to pumping andproduction of said fluids.
 32. The method of claim 27, wherein saidreadable ID code is read by a reader moved by gravity.
 33. The method ofclaim 27, wherein said readable ID code is read by a reader moved bybuoyancy in said fluid.
 34. The method of claim 27, wherein saidreadable ID code is read by a reader moved by self-propulsion.
 35. Themethod of claim 27, wherein said reader takes action upon reading saidreadable ID code.
 36. The method of claim 35, wherein said actionreleases mechanical keys.
 37. The method of claim 35, wherein saidaction upon reading said readable ID code is actuating an electrical,electromagnetic, magnetic, pneumatic, hydraulic, radioactive, or fiberoptic circuit.
 38. The method of claim 35, wherein said action uponreading readable ID code initiates measurements.
 39. The method of claim35, wherein said action upon reading readable ID code is communicatingwith a unique identifier to equipment along a length of and including anuphole surface of said borehole.
 40. The method of claim 39, whereinactuating communications is accomplished directly or remotely usingwired or wireless communications.